Full-opening well tool



Dec. 3, 1968 P. NUTTER FULL-OPENING WELL TOOL 8 Sheets-Sheet 1 FiledMarch 6, 1967 9/70/7707 Waffer INVENTOR.

Dec. 3, 1968 B. P. NUTTER FULL-OPENING WELL TOOL 8 Sheets-Sheet 2 F v,e. 5 HM m w A Po fl Filed March 6, 1967 Dec. 3, 1968 Filed March 6, 1967B. P. NUTTER 3,414,061

FULL-OPENING WELL TOOL 8 Sheets-Sheet 5 INVENTOR.

Dec. 3, 1968 B. P. NUTTER FULL-OPENING WELL TOOL 8 Sheets-Sheet 4 FiledMarch 6 JNVEN'TOR.

Dec. 3, 1968 B. P. NUTTER FULL- OPENING WELL TOOL Filed March 6, 1967/f/ZZSD v ZMLA Ben 2707? R 8 Sheets-Sheet 5 Dec. 3, 1968 B. P. NUTTERFULL-OPENING WELL TOOL 8 Sheets-Sheet 6 Filed March 6 1967 Be/yam) f./Vu zzer 206 INVENTOR. WM

AIIO/Fg Dec. 3, 1968 Filed March 6 8 Sheets-Sheet 7 .V W. #w T 0N Q mm w9 0,} m j Y W 0/ B 6 a 34 0/ Z a x: Z w

Dec. 3, 1968 B. P. NUTTER 3,414,061

FULL OPENING WELL TOOL Filed March 6, 1957 a shets-sheet'e fi f0 F 1-7 a-vw H' y JJ l' 145 1 5 4; flew/am? 44/ lfer INVENTORY ZKdOM Q.

JTTORN United States Patent 3,414,061 FULL-OPENING WELL TOOL Benjamin P.Nutter, Houston, Tex., assignor to Schlumberger Technology Corporation,Houston, Tex., a corporation of Texas Filed Mar. 6, 1967, Ser. No.620,841 24 Claims. (Cl. 166-226) ABSTRACT OF THE DISCLOSURE Thisdisclosure pertains to full-bore well tools and particularly describes atool having a so-called ball valve controlling communicationtherethrough. To actuate the ball valve, an actuating member connectedthereto is associated with suitable biasing means normally engaged incompression between first and second opposed shoulders on the actuatingmember and tool housing to hold the valve in one position. When the toolmandrel is moved to operate the ball valve, the actuating member ismoved in such a manner that the biasing means are disengaged frombetween the first and second shoulders and then brought into engagementwith third and fourth shoulders so arranged that further movement of themandrel will develop an increased biasing force suflicient to move thevalve to its other position. Means are also disclosed for releasablysecuring the valve in its other position while the mandrel is moved tothe further positions. Means are also described whereby testing devicescan be releasably secured in the tool and selectively released uponopening of the ball valve.

Accordingly, as will subsequently become apparent, the present inventionrelates to well tools; and, more particularly, pertains to well toolscapable of reliably performing testing or treating operations as well asbeing selectively operable to provide an unrestricted central passagetherethrough.

It is customary to dependently couple a number of different full-boretools from a tubing string for performing such operations as testing aformation under flowing or static conditions, squeeze cementing,acidizing or fluidfracturing. Such a string of full-bore tools usuallyincludes a full-bore packer for packing-off the well bore to remove thehydrostatic pressure of the well control fluid from the formations belowwhere the packer is set. In a number of these operations, it ispreferred that the lower end of the tubing string be initially closedabove the packer to prevent fluids in the well bore from entering thetubing string as the tools are being positioned. Thus, by keeping thetubing string dry, it will be unnecessary to remove fluids from thetubing by swabbing or gas displacement before testing or completionoperations can be started. Moreover, by selectively closing the lowerend of the tubing string, treating fluids can be placed in the tubingstring and selectively discharged below the packer without beingcontaminated by fluids in the well as the tools are being shifted fromone position to another.

In addition to selectively controlling fluid communication, it isparticularly desirable to have a tool so versatile that it can also beopened to leave an unrestricted axial passage large enough to passvarious completion tools as well as high flow rates of cement orfracturing fluids. Although various tools having a full-opening passagehave been used heretofore, such tools normally employ either a removablecenter section or else a flapper or ball valve that must be openedagainst the full differential pressure across the tool. In addition tobeing more complex, tools with removable center sections require specialretrieving equipment and these center sections must be replaced toreclose the central passage. On the other hand, although those toolsusing pivoted flapper valves are less complex and can be reclosed whendesired, it is not uncommon that these valves are damaged when openedagainst differential pressures.

Ball valves are generally preferred over flapper valves since a flappervalve can not be fully seated should debris or the like become lodged onthe valve seat while the flapper is open. A ball valve is not subject tothis hazard, however, since the ball member is always seated and ismerely rotated on its seat between its open and closed positions.

Heretofore, ball valves have not been too reliable because of thedifliculties in opening and closing them without damaging either theball member or its pivots. For example, it will be recognized that toopen a ball valve, suflicient force must be applied to the ball memberto rotate it against the frictional forces between it and its seat thatare imposed by pressure differentials across the valve. Spacelimitations in a well tool necessarily reduce the size of the pivots fora ball member so that a substantial pressure differential across theball member can require so much force to rotate the ball member to itsopen position that the pivots might fail. On the other hand, even thoughthe tool is so arranged that the pressure differential across the valvewill be reduced or equalized as it opens, a spring or the like stillmust be employed to provide a rotational force. Even though such springsare much weaker than they would have to be to rotate the ball memberagainst a pressure differential, they still impose a positive forcetending to open the ball member even while the valve is closed. Thus,unless additional precautions are taken, a shock on the tool as it movesthrough a well bore may well open the ball member prematurely. Tocounteract this latter problem, additional springs are usually employedto hold the ball member closed until the valve is to be opened. Suchmeasures, however, only result in longer tools and require carefulselection of the springs to maintain a proper balance.

It is also necessary at times to secure a ball member in its openposition. Typically this requires that the mandrel of the tool beimmobilized to hold the ball valve open. Thus, unless specialarrangements are made to allow for the immobility of the mandrel, themandrel can not be moved to perform other operations so long as the ballmember is locked open.

Accordingly, it is an object of the present invention to provide a newand improved well too] having a ball valve that is easily moved betweenits open and closed positions but will reliably remain in either ofthese positions without risk of being unknowingly moved should the toolbe subjected to a severe shock.

It is a further object of the present invention to provide a new andimproved well tool with means for releasably latching the ball valve inone of its positions so that the mandrel can be moved to other positionswithout disturbing the ball valve.

It is still another object of the present invention to provide new andimproved releasable barrier means for such well tools that can bereleased whenever the ball valve is open.

These and other objects of the present invention are obtained bytelescopically arranging an inner tubular member or mandrel within anouter tubular housing for movement therein between an extending positionand successively telescoped positions. First valve means are providedfor selectively opening and closing fluid communication between thetubular members and a rotatable cylindrical or spheroidal valve memberwith a flow passage therethrough is pivotally mounted to the mandrel andseated on an annular valve seat mounted on the lower end of the mandrel.Spring means are appropriately arranged to hold the valve member in oneof its positions until the mandrel is moved from one of its positions toanother one of its positions. Then, as the mandrel is moved to stillanother of its positions, the spring means will impose a suflicientrotational force on the valve member that it will rotate to its secondposition.

As a further aspect of the present invention, the mandrel may be dividedinto separable portions that are releasably latched together. Once themandrel is moved to one of its aforementioned positions, the mandrel 1smanipulated to release the lower mandrel portion from the upper portion.Then, the latch means can be employed to secure the lower mandrelportion and valve member in position and free the upper mandrel portionfor further movement without affecting the valve memher.

To provide a releasable barrier in the well tool, the present inventionfurther includes several embodiments of devices that, when needed, mayeither be loosely seated below the ball member or be seated andreleasably held in position there.

The novel features of the present invention are set forth withparticularity in the appended claims. The operation, together withfurther objects and advantages thereof, may best be understood by way ofillustration and example of certain embodiments when taken inconjunction with the accompanying drawings, in which:

FIG. 1 shows a typical string of well tools in a well bore including atool employing the principles of the present invention;

FIGS. 2A2D are successive elevational views, partially in cross-section,of one embodiment of a well tool arranged in accordance with the presentinvention;

FIGS. 3 and 4 are cross-sectional views taken along the lines 33 and 4-4respectively in FIG. 2A;

FIGS. SA-SF are somewhat schematic views of the well tool shown in FIGS.2A2D and depict its successive operating positions;

FIG. 6 is an elevational view of a portion of another embodiment of awell tool with the selectively operable latch means of the presentinvention;

FIGS. 7 and 8 are cross-sectional views taken along the lines 7 and 8respectively in FIG. 6;

FIG. 9 is an elevational view of measuring apparatus adapted for beingreleasably secured in either of the tools depicted in FIGS. 2A2D or inFIG. 6; and

FIGS. 10 and 11 respectively show alternate embodiments of selectivelyreleasable measuring apparatus similar to that shown in FIG. 9.

Turning now to FIG. 1, a number of full-bore well tools 23 are showntandemly connected to one another and dependently coupled from the lowerend of a string of pipe, such as a tubing string 24, suspended in acased well bore 25. At the lower end of these tools, a conventionalfull-bore packer 23 is arranged for selectively packing-ofl the casing25. A typical hydraulic holddown 22 is coupled to the mandrel 26 of thepacker 23 and arranged to engage the casing 25 to secure the mandrelagainst the upward movement whenever the packer is set and fluidpressure within the tubing string 24 exceeds the hydrostatic pressure ofthe well control fluids in the well annulus. A typical bypass valve 21,coupled by a tubing sub 27 above the holddown 22, is suitably arrangedto be opened and facilitate shifting of the tools 2023 within thefluid-filled casing 25 by diverting a substantial portion of the fluidsthrough the central bore of the retracted packer 23. Connected at theupper end of the tools 2123 is a tool 20 incorporating the principles ofthe present invention. Although the tools 2123 may be those shown onpage 3057 of the 19606l Composite Catalog of Field Equipment andService, it will be understood, of course, that other tools of a similarnature could also be used in conjunction with the tool 20.

Turning now to FIGS. 2A2D, successive elevational views, with each beingpartially in cross-section, are

shown of the tool 20. The tool 20 includes a tubular mandrel 28telescopically disposed within a tubular housing 29 and arranged forselective longitudinal movement therein between an extended position asshown in FIGS. 2A2D, one or more intermediate positions, and a fullytelescoped position as subsequently described with reference to FIGS.5A-5F. A threaded collar 30 (FIG. 2A) on the upper end of the mandrel 28is arranged for coupling to the tubing string 24 (FIG. 1), with thecentral bore 31 (FIGS. 2A2D) of the mandrel having substantially thesame internal diameter as that of the tubing string. Similarly, threads32 (FIG. 2D) are arranged on the lower end of the housing 29 forcoupling the tool 10 to the other well tools therebelow.

In general, the tool 20 includes first and second valve means 33 and 34(FIG. 2C) arranged in accordance with the invention that are eachselectively opened and closed by shifting the mandrel 28 between itsvarious longitudinal positions with respect to the housing 29. Forestablishing these longitudinal positions, selectively operableposition-establishing means 35 (FIG. 2A) are provided. Theseposition-establishing means 35 are preferably arranged as described in acopending application Serial No. 620,943 filed by the present inventoron the same day as the present application. When theposition-establishing means 35 are employed, means, such as clutches 36and 37, are also provided to permit selective application of torque fromthe mandrel 28 through the housing 29 to the other tools 2123 when themandrel is in certain ones of its positions.

Turning now to FIG. 2A, the uppermost portion of the tool 20 is shown.As seen there, the clutch 36 is arranged to co-rotatively secure themandrel 28 to the housing 29 when the mandrel is in its lowermost orfully telescoped position. Similarly, the clutch 37 co-rotativelysecures the mandrel 28 and housing 29 when the mandrel is in itsuppermost or fully extended position relative to the housing. The clutch36 is comprised of an annular member 38 that is co-rotatively securedover the collar 30 on the upper end of the mandrel 28 and has one ormore depending lugs 39 thereon adapted for reception in a correspondingnumber of upwardly facing longitudinal slots 40 in the upper end of thehousing 29 whenever the mandrel is in its lowermost position relativethereto. A threaded ring 41 threadedly secured to the collar 30 abovethe member 38 retains the annular member in position as well asfacilitates its removal for disengaging the lugs 39 from the slots 40after the tool 20 is removed from the well bore 25 The clutch 37includes an annular member 42 that is slidably mounted in the uppermostend of the housing 29 below an inwardly directed housing shoulder 43 andcorotatively secured thereto by external longitudinal grooves adapted toreceive complementary longitudinal splines 44 (FIG. 3) projectinginwardly from the internal wall of the housing. Inwardly projectingscrews 45 are arranged in the housing 29 for reception in longitudinalslots 46 in the annular member 42 to limit the downward longitudinaltravel of the annular member. External longitudinal splines 47 (FIGS. 2Aand 3) on the mandrel 28 and immediately above an external shoulder 48thereon are adapted for reception in complementary longitudinal splinegrooves 49 (FIG. 3) in the internal wall of the annular member 42.

A spring 50 between the housing shoulder 43 and the upper end of theannular member 42 normally urges the annular member downwardly againstthe lower stop 48 but permits it to retrogress should the mandrelsplines 47 not be in registry with their complementary grooves 49 as themandrel 28 is being moved upwardly. It will be understood, of course,that even though the mandrel splines 47 may not be initially inalignment with the spline grooves 49, rotation of the mandrel 28 ineither direction will quickly bring the splines into orientation withtheir grooves and the spring 50 will then urge the annular clutch member42 downwardly over the splines.

Accordingly, it will be appreciated that so long as the mandrel 28 is inits extended position (as seen in FIGS. 2A-2D) with respect to thehousing 29, the mandrel is co-rotatively secured thereto by the clutch37. Downward movement of the mandrel 28 toward its intermediatepositions will, however, shift the mandrel splines 47 out of the splinegrooves 49 and allow the mandrel to be rotated relative to the housing29 until the mandrel reaches its fully telescoped or lowermost position.The mandrel 28 will again be co-rotatively secured by the clutch 36 tothe housing 29, however, once the mandrel is moved to its lowermostposition and the lugs 39 enter the slots 40.

As described in the aforementioned copending application, theposition-establishing means 35 shown in FIG. 2A below the clutch 37 arecomprised of radially expansible gripping means such as two segmentedsplit-nuts 51 and 52 placed at longitudinally spaced positions in ahousing recess or the annular clearance space 53 between the mandrel 28and the housing 29. As best seen in FIG. 4, longitudinal splines 54 oneach of the segments of the nuts 51 and 52 are complementarilyinterlocked in grooves 55 in the internal wall of the housing 29 toco-rotatively secure the split-nuts to the housing. As seen in FIG. 2A,inwardly directed housing shoulders 56 and 57 above and below the nut,respectively, limit the longitudinal travel of the lower split-nut 52.The upper split-nut 51 is held against longitudinal movement by anannular spacer 58 above the nut that is engaged with the housing 29 andan inwardly directed shoulder 59 below the nut.

Oppositely directed buttress threads 60 and 61 are appropriately spacedat longitudinal intervals around the mandrel 28 and respectivelyarranged for selective engagement with complementary threads in the nuts51 and 52 in certain longitudinal positions of the mandrel. The uppermandrel threads 60 are faced upwardly and are preferably so-calledleft-hand threads arranged to threadedly engage the downwardly facingthreads in the upper split-nut 51. With this arrangement, downwardlongitudinal movement of the mandrel 28 will allow the upper mandrelthreads 60 to be ratcheted freely into the upper split-nut 51 butprevent upward longitudinal movement of the mandrel until it is rotatedin a clockwise or right-hand direction to unthread the upper mandrelthreads from the upper split-nut. Similarly, the lower mandrel threads61 are faced downwardly and are so-called righthand threads. Toaccommodate the lower mandrel threads 61, the threads in the lowersplit-nut 52 are faced upwardly. Thus, release of the mandrel threads 61from the lower split-nut 52 for downward movement of the mandrel 28 canbe accomplished only by rotating the mandrel in a clockwise direction tounthread these members. It will be appreciated, of course, that byfacing the mandrel threads 61 and those in the lower split-nut 52 inopposite direction, upward movement of the mandrel 28 will cause thelower mandrel threads to freely ratchet through the lower split-nut.

For reasons that will subsequently become more apparent, the lowermandrel threads :61 are normally engaged with the lower split-nut 52 andthe upper threads 60 are normally disengaged from the upper split-nut 51and spaced a particular distance thereabove. Thus, with the lowermandrel threads 61 engaged with the lower split-nut 52 as shown in FIG.2A, the mandrel 28 is free to travel longitudinally with respect to thehousing 29 only so far as is permitted by the distance between thespaced housing shoulders 56 and 57 respectively above and below thelower split-nut. Similarly, as will also subsequently become apparent,whenever the upper mandrel threads 60 are threadedly engaged with theupper split-nut 51, the mandrel 28 will be secured in its lowermosttelescoped position and cannot be returned to its intermediate orextended positions since the upper splitnut is held by the spacer 58 andthe co-engagement of the lugs 39 and slots 40 prevent further rotationof the mandrel with respect to the housing 29. It will be recalled thatthe lugs 39 cannot be disengaged from the slots 40 until the tool 20 isreturned to the surface and the threaded collar 30 is removed to permitdisengagement of the clutch 36.

Turning now to FIG. 2B, the intermediate portion of the tool 20 is shownin which are located pressure-biasing means 62 and, for the enhancementof the positionestablishing means 35, movement-retarding means 63.Biasing means 62 are preferably provided to maintain a downward force onthe housing 29 to assist in keeping the packer 23 seated while themandrel 28 is being moved as well as to apply an upward force on themandrel to keep the clutch 37 engaged whenever the mandrel is in itsfully extended position with respect to the housing. Thepressure-biasing means 62 are comprised of an enlarged-diameter shoulder64 on the mandrel 28 that is fluidly sealed by O-rings 65 within areduced-diameter portion 66 of the housing 29 above an external housingport 67 and an annular slidable piston member 68 that is around themandrel above its enlarged-diameter shoulder 64 and below anotherexternal housing port 69. O-rings 70 and 71, respectively, inside andoutside of the slidable piston 68 fluidly seal the piston to the mandrel28 and housing 29 so as to provide a fluid-tight annular space 72between the piston and the enlarged-diameter mandrel shoulder 64, whichspace is normally at atmospheric pressure. A spring 73 between aninwardly directed housing shoulder 74 and the upper end of the piston 68normally urges the piston downwardly against a shoulder 75 defined bythe upper end of the reduceddiameter housing portion 66.

It will be recognized that well control fluids will enter the ports 69and 67 above the piston 68 and below the enlarged-diameter mandrelportion 64 as the tool 20 is being used. Inasmuch as the annular space72 is normally at atmospheric pressure, the hydrostatic pressure of thewell control fluids will therefore tend to lift the mandrel 28 by aforce equal to the ditference between the hydrostatic and atmosphericpressures multiplied by the annular cross-sectional area of theenlarged-diameter mandrel shoulder 64 itself. The cross-secti onal areaof the mandrel 28 itself will, of course, be subjected to both upwardlyand downwardly acting pressure forces. Similarly, the piston 68 will beurged downwardly against the housing shoulder 75 by a force equal to thedifference between the hydrostatic and atmospheric pressures multipliedby the annular cross-sectional area bounded by O-rings 65 and 70.

Thus, it will be appreciated that since the mandrel 28 is urged upwardlyby this unbalanced pressure force, a force at least greater than thisupwardly directed pressure force must be applied to the mandrel in orderto move it downwadly relative to the housing 29. Similarly, it will beappreciated that the downwardly acting pressure force on the piston 68is effective through the housing shoulder 75 to impose a correspondingdownwardly directed force thereon which will be transmitted through thehousing to the mandrel 26 of the packer 23 (FIG. 1) to assist in keepingthe packer seated.

Although the piston 68 could be made an integral portion of the housing29, it is preferred to make it a separate member as shown in FIG. 2B andto provide a small lateral port 76 in the housing immediately above thenormal position of the external O-ring 71. In this manner, should wellcontrol fluids leak into the enclosed annular space 72, as the tool 20is being removed from the well bore 25, any excessive pressure in theenclosed space 72 will be vented through the port 76 whenever thistrapped pressure is suflicient to lift the piston 68 against therestraint of the spring 73 a suflicient distance to move the O-ring 71above the port 76. This arrangement also insures that the mandrel 28 canbe returned upwardly should fluids leak into the space 72 after themandrel is lowered. Otherwise, the piston 68 could just as well be madean integral portion of the housing 29.

The movement-retarding means 63 are comprised of a sleeve 77 looselydisposed between longitudinally spaced, enlarged-diameter portions 78and 79 of the mandrel 28, with only a limited annular clearance 80 being left between the mandreland sleeve and a very minute annularclearance 81 being left between the sleeve and the inner wall of thehousing 29. A compression spring 82 between the sleeve 77 and the lowerenlargeddiarneter mandrel portion 79 normally urges the sleeve upwardlyagainst the upper enlarged-diameter mandrel portion 78. An O'ring 83(FIG. 2C) around the internal wall of an inwardly facing shoulder 84 inthe housing 29 fluidly seals the mandrel 28 and housing relative to oneanother and defines a fluid-tight space 85 therebetween below the sleeve77. An annular piston 86 (FIG. 2B) having internal and external O-rings87 and 88 is provided just below the housing port 67 to fluidly seal thehousing 29 relative to the mandrel 28 and define a second fluid-tightspace 89 therebetween above the sleeve 77. In this manner, the separatefluid-tight spaces 85 and 89 are able to communicate with one anotheronly by way of the annular clearance spaces 80 and 81 inside of andaround the sleeve 77 respectively. A suitable hydraulic fluid, such asan oil or the like, fills the fluidtight spaces 85 and 89.

It Will be appreciated that the hydrostatic pressure of the well controlfluids will be effective through the port 67 against the piston 86 tomaintain the oil in the spaces 85 and 89 at the same pressure.Accordingly, the speed of longitudinal movement of the mandrel 28 withrespect to the housing 29 will be governed by the rate at which the oilcan be displaced from one to the other of the fluidtight spaces 85 and89. Downward movement of the mandrel 28 with respect to the housing 29will, of course, maintain the lower face 90 of the upperenlarged-diameter mandrel portion 78 tightly engaged against theadjacent upper face 91 of the sleeve '77. By appropriately machining theabutting surfaces 90 and 91 of the shoulder 78 and sleeve 77, ametal-to-metal seat is effected to close the internal annular space 80and make the minute external annular clearance space 81 the only flowpath by which oil can be transferred from the lower space 85 to theupper space 89 as the mandrel 28 is moved downwardly. In this manner,the time required to move the mandrel 28 downwardly with respect to thehousing 29 will be directly related to the dimensions of the externalannular clearance space 81 and the viscosity of the oil in thefluid-tight spaces 85 and 89. If it is desired, the lower space 85 maybe slightly enlarged, as at 92, so that whenever the mandrel 28 hasmoved downwardly at this controlled rate a predetermined distance withrespect to the housing 29, it can continue moving further downwardlywith added relative freedom.

To permit fairly rapid upward movement of the mandrel 28 with respect tothe housing 29, the internal clearance space 80 between the sleeve 77and mandrel is made somewhat larger than the external clearance space81. It will be understood, of course, that the spring 82 is notsufficiently strong to keep the sleeve end 91 abutted against its matingsurface 90 on the shoulder 78 whenever the mandrel 28 is being movedupwardly. Thus, whenever the mandrel 28 is pulled upwardly with respectto the housing 29, the sleeve 77 will shift slightly downwardly and movethe seating surfaces 90 and 91 apart so as to allow oil from the upperspace 89 to pass relatively free between these surfaces, through thelarger annular clearance 80, and on into the lower fluid-tight space 85.

Turning now to FIGS. 2C and 2D, the lowermost portion of the tool isshown in which are located the first and second valve means 33 and 34(FIG. 2C) of the present invention. The internal diameter of thisportion of the housing 29 is preferably increased to provide an enlargedbore, as at 93, below the enclosed space and above an upwardly directedhousing shoulder 94 (FIG. 2D) near the lower end of the housing.

The first valve means 33 (FIG. 2C) are preferably arranged as atelescoping sleeve valve adapted to control fluid communication betweenthe enlarged housing bore 93 and the internal bore 31 of the mandrel 28so long as the second valve means 34 therebelow are closed. These firstvalve means 33 include a coaxially arranged tubular member 95 that isdependently secured within the housing 29 and extended downwardly intothe enlarged housing bore 93. Lateral ports 96 in the mandrel 28 areadapted to be moved into registry with corresponding lateral ports 97 inthe coaxially arranged tubular member 95 whenever the mandrel is movedinto one of its intermediate longitudinal positions with respect to thehousing 29. O-rings 98 and 99 respectively above and below the mandrelports fluidly seal the mandrel 28 relative to the tubular member 95 toblock flow through the ports 96 and 97 whenever they are not inregistration in the other positions of the mandrel.

The second valve means 34 of the present invention includes a sphericalvalve member 100 having an axial passageway 101 therethrough along oneof its central axes that is sized to correspond at least approximatelyto the internal mandrel bore 31. The ball member 100 is operativelydisposed between a pair of opposed, longitudinally spaced, annular seats102 and 103 having complementary spherical seating surfaces. One of thevalve seats 102 is coaxially mounted in a complementary counterbore inthe lowermost end of the mandrel 28 between a pair of dependinglongitudinal lugs 104 (only one seen) extending downwardly from thelower end of the mandrel 28 on opposite sides of the seat. The ballmember 100 is pivotally supported between the free ends of thesedepending lugs 104 about another of its central axes by appropriatelylocated transverse pivots 105 (only one seen) that are so positionedthat the ball member will remain seated on the seat 102 as the ballmoves between its open and closed positions. The axis of these pivots105 is, of course, perpendicular to the central axis of the passageway101 so that as the ball member 100 is pivoted, the passageway will moveinto an out of registration with the valve seat 102. It will beappreciated, of course, that so long as it has a curved portioncomplementary to the valve seat 102 the valve member 100 could also be acylinder or a hemisphere that is pivoted about its central axis.

The other valve seat 103 is coaxially mounted in an upwardly facing,complementary counterbore 106 formed in the upper end of an elongatedtubular member 107 that is loosely disposed immediately below the ballmember 100 in the enlarged housing bore 93 and fluidly sealed therein byan O-ring 108 around its upper end. The valve seat 103 is preferablysupported by its receptive counterbore 106 by a spring 109 and fluidlysealed therein by an O-ring 110.

A pair of upwardly extending lugs 111 and 112 (only one lug of each pairseen) are arranged on the upper end of the tubular member 107 oppositesides of the valve seat 103 to straddle the ball member 100, with eachof these lugs being laterally displaced from the central axis andextended upwardly alongside the opposite side of the depending lugs 104.Each associated set of lugs 104, 111 and 112 are so arranged that theiropposed longitudinal edges, as at 113 and 114, are in juxtaposition withone another. To transmit an eccentric turning force to the ball member100, inwardly projecting transverse pins 115 (only one seen) on the freeends of the lower lugs 111 are dis-posed parallel to the axis of thepivots 105 but longitudinally spaced therebelow and slightly offset toone side. The free ends of these pins 115 are each confined withinfairly short, inclined grooves 116 (only one seen) formed in theadjacent external surfaces of the ball member 100. It will be noted thatthe pivots 105 normally support the ball member 100 off of the lowerseat 103 so as to leave an annular clearance, as at 117, therebetween solong as the ball member is in its closed position as seen in FIG. 2C.

Accordingly, it will be appreciated that whenever the ball member 100 ismoved toward the tubular member 107 and valve seat'103, the ball will bepivoted by the pins 115 and slots 116 about its pivots 105 in aclockwise direction as seen in the drawings. It will be realized, ofcourse, that the cooperative engagement of the juxtaposed edges 113 and114 of the lugs 104, 111 and 112 will prevent the mandrel 28 and tubularmember 107 from rotating relative to one another and limit theirrelative motion to rectilinear travel. The inclined grooves 116 must, ofcourse, be of sufiicient length to accommodate the transverse pins 115whenever the ball member 100 has rotated midway between its fully-closedand its fully-open positions.

To actuate the valve means 34, biasing means are provided such as acompression spring 118 (FIG. 2D) that is disposed around the tubularmember 107 between spaced, annular abutment members 119 and 120 slidablydisposed thereon and supported by an external shoulder 121 on the lowerend of the tubular member 107. An inwardly directed housing shoulder 122is suitably located to normally engage the upper face of the upperabutment 119 whenever the tool is in the position shown in FIGS. 2A-2D.So long as the tool 20' is in the depicted position, the spring 118 willbe acting between the shoulders 121 and 122 to urge the tubular member107 downwardly and, as a result, bias the valve member 100 in its closedposition.

It will be noted that in this position of the tool 20, the lower face ofthe lower abutment 120 is spaced above the housing shoulder 94 adistance equal to the longitudinal spacing of the ports 96 and 97.Similarly, this same longitudinal spacing is maintained between theupper face of the upper abutment 119 and the lower face 123 of anenlarged-diameter portion or shoulder 124 at the upper end of thetubular member 107. The shoulder 124 is, of course, suitably sized topass freely through the annular housing shoulder 122. Moreover, forreasons that will subsequently become apparent, these longitudinalspacings are greater than and, preferably, about double the maximumlongitudinal spacing between the upper face of the housing shoulder 57and the lower face of the lower split-nut 52 (FIG. 2A) when thissplit-nut is engaged with the lower portion of the mandrel threads 61.

Accordingly, it will be appreciated that when the mandrel 28 is in itsextended position with respect to the housing 29 as shown in FIGS.2A-2D, both valve means 33 and 34 are closed. However, by moving themandrel 28 downwardly with respect to the housing 29 the above-mentionedlongitudinal distance to one of its intermediate positions (to besubsequently described in greater detail), the first valve means 33 willbe opened to provide fluid communication from the enlarged housing bore93, through the clearance at 117 around the ball member 100 and throughthe ports 96 and 97, and on into the central bore 31 of the mandrel 28.The ball member 100 is still in a closed position in this intermediateposition of the mandrel 28. Similarly, as will be subsequently describedwith greater detail, further downward movement of the mandrel 28 (againthis same longitudinal distance) will reclose the first valve means 33and open the second valve means 34 as the mandrel reaches its lowermost,telescoped position. In this latter position, a full-opening passage isprovided through the tool 20 since the passageway 101 in the ball member100 will now have been rotated into alignment with the central mandrelbore 31.

Turning now to FIGS. SA-SF, the tool 20 is schematically represented toillustrate each of its various positions during the course of a typicaloperating sequence. To facilitate the explanation of the invention, thebiasing means 62 and movement-retarding means 63 are not shown in FIGS.SA-S-F. It will be understood, nevertheless, that downward travel of themandrel 28 will be regulated by the movement-retarding means 63 untilthe top of the sleeve 77 has entered the enlarged space 92- (FIG. 2B).Similarly, it should be kept in mind that the biasing means 62 will beeffective to provide an upwardly directed force on the mandrel 28 and toapply an equal, but downwardly directed, force on the housing 29 duringthe entire operation of the tool 20.

In FIG. 5A, the tool 20 is shown with the mandrel 28 being in itsuppermost extended position with respect to the housing 29 as alreadydescribed with reference to FIGS. 2A-2D. The first and second valvemeans 33 and 34 are closed to block fluid communication through themandrel bore 31 as the tools 20-23 are moved into position in the casedwell bore 25 (FIG. 1). It will also be noted from FIG. 5A that althoughthe upper clutch member 38 is disengaged, the lower clutch member 42 isengaged to permit rotation to be applied from the tubing string 24,through the tool 20, and on to the other tools 21-23 therebelow.Accordingly, with the tool secured in the position depicted in FIG. 5A,the tools 20-23 can be brought into position at any desired depth in thecased well bore 25.

Once the tools 20-23 have reached a desired position in the well bore25, they are momentarily halted and the tubing string 24 is manipulatedas required to set the packer 23 so that their respectiveposition-establishing tools may utilize different movements for theiroperation, it is preferred to arrange the bypass valve 21 and packer 23so that their respective position-etsablishing means, such a J-slotsystems (not shown), in each tool will work in cooperation to close thebypass valve as the packer is being set. Accordingly, with the tools 21and 23 having cooperative J-slot systems arranged in this manner, thetubing string 24 is picked up slightly and torqued in a clockwisedirection to unjay the bypass valve and packer. Then, by slacking-off atleast part of the weight of the tubing string 24, the packer 23 will beset and the bypass valve 21 closed. It will be recalled that the mandrel28 cannot move downwardly relative to the housing 29 until the upwardforce provided on the mandrel by the biasing means 62 is overcome.

Once the packer 23 is set, it will be appreciated that it is capable ofsupporting the full weight of the tools 20- 22 and tubing string 24thereabove. The housing 29 of the tool 20 will, of course, now be fixedrelative to the easing 25 until the packer 23 is unseated. It. will berecalled, moreover, that the biasing means 62 will also be effective tomaintain a substantial downward force through the housing 29 to aid inholding the packer 23 seated. Thus, the mandrel 28 of the tool 20 willnow be capable of being moved relative to the now-stationary housing 29by corresponding motions of the tubing string 24 to bring the tool intoits various operating positions.

-Accordingly, as shown in FIG. 5B, application of weight to the mandrel28 for setting the packer 23 will carry the mandrel a short distancedownwardly (as shown by arrow 125) until the lower split-nut 52 engagesthe upwardly facing shoulder 57. This downward movement will, however,be retarded by the movement-retarding means 63 and furthermore willrequire sufiicient weight on the mandrel 28 to at least overcome theupwardly directed force on the mandrel provided by the biasing means 62.It will be noted from FIG. 5B, however, that this initial downwardtravel of the mandrel 28 is not sufiicient to open either the valvemeans 33 or 34 and that the only significant change in the tool 20 willbe to disengage the lower clutch member 42. Thus, downward motion androtation of the tubing string 24 in these first two operating positionsof the tool 20 will be effective only to set the packer 23 and close thebypass valve 21 without introducing any risk whatsoever that either ofthe valve means 33 and 34 might be opened prematurely by overmovement ofthe mandrel 28.

It will also be appreciated from FIG. 5B that further downward travel ofthe mandrel 28 relative to the housing 29 is not possible so long as thelower nut 52 is abutted on the housing shoulder 57. On the other hand,upward travel of the mandrel 28 is unimpeded should, for example, it benecessary to re-engage the lower clutch member 42 to apply rotation fromthe tubing string 24 through the housing 29 to the tools 2123.Accordingly, to continue further downward travel of the mandrel 28, itis necessary to first unthread the lower mandrel threads 61 at leastpartway through the lower nut 52. It will be realized, of course, thatunthreading rotation of the mandrel 28 would ordinarily tend to move themandrel on downwardly and leave the lower split-nut 52 shouldered on itsassociated lower housing shoulder 57.

Then, as best seen in FIG. 5C, rotation of the mandrel 28 in theappropriate direction (as shown by arrow 126) in cooperation with themovement-retarding means 63 will instead cause the lower split-nut 52 toclimb the mandrel threads 61 and leave the mandrel in substantially thesame longitudinal position as before. The nut 52 cannot, of course,rotate by virtue of the splines 54 (FIG. 4) but it will neverthelessclimb the threads 61 as the mandrel 28 rotates relative to thesplit-nut.

Once the split-nut 52 reaches the upper limit of its travel asdetermined by the housing shoulder 56, further rotation of the mandrel28 will be ineffective and the lower split-nut will only alternatelyexpand and contract within the recess 53 until the rotation is halted.It will be understood, of course, that the time delay provided by themovement-retarding means 63 is such that the lower nut 52 can climb themandrel thread 61 to its next intended position thereon beforesignificant downward travel of the mandrel 28 can occur.

Once the lower nut 52 has engaged the upper shoulder 56, the mandrel 28will again be capable of traveling further downwardly to re-engage thesplit-nut on its associated lower shoulder 57. The rate of this downwardtravel will, of course, still be governed by the movementretarding means63. Thus, as best seen in FIG. 5D, once a sutficient length of time haselapsed, downward force (as shown by arrow 127) on the mandrel 28 inexcess of the opposing upward force of the biasing means 62 will serveto carry the mandrel downwardly until the lower split-nut 52 againengages the lower housing shoulder 57. At this point, by appropriatelyspacing the ports 96 and 97 in relation to the vertical height of thenut 52 and the spacing between the opposed shoulders 56 and 57, theports of the first valve means 33 will be in registry whenever the lowernut 52 is shouldered on the lower shoulder 57 and is at its desiredsecond position as, for example, at the top of the mandrel threads 61.

Once the ports 96 and 97 are open, fluid communication will beestablished between the Well bore below the seated packer 23 and, by wayof the intervening tools 21 and 22, into the mandrel bore 31 and tubingstring 24 thereabove. The ball valve means 34 will, however, remainclosed. Thus, fluids may either be introduced from the tubing string 24,through the ports 96 and 97 and the clearance 117, and on into the wellbore 25 below the packer 23 or received therefrom depending upon thenature of the completion or treating operation. Opening of the ports 96and 97 will also equalize any pressure differential that would otherwisebe acting across the ball member 100 so long as it was closed. It willbe appreciated, moreover, that the ports 96 and 97 may be reclosed andreopened as many times as desired merely be picking up and returning thetool 20 to the position shown in FIG. 5A.

To open the second valve means 34, it is, of course, necessary to movethe mandrel 28 further downwardly than permitted by the engagement ofthe lower split-nut 52 (as now positioned on the threads 61) with itsassociated lower shoulder 57 (FIG. 5D). Accordingly, as best seen inFIG. 5B, the mandrel is again rotated (as shown by arrow 128), whichrotation causes the lower split-nut 52 to climb still further up themandrel threads 61 until it is completely disengaged therefrom. Themovement-retarding means 63 will again serve to prevent correspondingdownward travel of the mandrel 28 until at least sufficient time haselapsed for the lower nut 52 to disengage itself from the mandrelthreads 61.

Once the lower mandrel threads 61 are freed from the lower split-nut 52,the mandrel 28 is then free to travel on downwardly as permitted by themovement-retarding means 63. Once the upper end of the sleeve 77 clearsthe enlarged-diameter housing portion 92, the mandrel 28 will then moverapidly downwardly (as shown by arrow 129) into the position depicted inFIG. 5F. This sudden movement will provide a substantial jar that iseasily detected at the surface. As seen in FIG. 5F, movement of themandrel 28 into this position will simultaneously co-engage the uppermandrel threads 60 with the upper splitnut 51, move the mandrel ports 96below the sleeve ports 97, and pivot the ball member 100 (as shown byarrow 130) into a position where its passageway 101 is coaxially alignedwith the mandrel bore 31. Then, if necessary, the tubing string 24 isrotated one or two rotations to insure engagement of the upper clutchmember 38. This will also provide a positive indication at the surfacethat the ball member 100 is open and the mandrel 28 and housing 29 areco-rotatively secured.

It will be appreciated that to pivot the ball member 100 into its openposition, the ball member must move downwardly relative to the tubularmember 107 with sufiicient force that the camming action of thetransverse pins in the slots 116 will rotate the ball member about itspivots 105. This upward force is, of course, provided by the spring 118which, as best seen in FIGS. S D-5F, is progressively compressed untilit develops a resisting force that is sufficient to rotate the ballmember 100 against the frictional forces imposed by the upper valve seat102. It will be recalled that opening of the ports 96 and 97 equalizedany pressure differential acting across the ball member 100 before itwas opened. Moreover, it will be realized that the spring 118 cannotdevelop an upwardly acting force until the lower abutment has engagedthe housing shoulder 94 and the shoulder 123 has engaged the upperabutment 119 as seen in FIGS. 5D and 5E. Then, as the mandrel 28 ismoved further downwardly as seen in FIG. 5F, the spring 118 isprogressively compressed to develop a correspondingly increasingupwardly directed bias through the upper abutment 119 to the shoulder123 of the tubular member 107. It is of particular significance that solong as the lower abutment 120 has not engaged the housing shoul der 94and the shoulder 123 has not engaged the upper abutment 119 (FIGS.5A5C), the spring 118 is acting between the shoulders 121 and 122 tourge the tubular member 107 downwardly. This downward force on thetubular member 107 will be effective through the transverse pins 115 tohold the ball member 100 in its closed position as shown in FIG. 2C.This action of the spring 118 is one of its two functions. It will beappreciated also that the shoulders 121 and 122 serve to isolate orspace the opposite ends of the spring 118 from the shoulders 94 and 123.

Accordingly, as the downward force 129 on the mandrel increases,downward movement of the tubular member 107 will now be restrained bythe force of the spring 118 as the shoulder 123 tends to move theabutment 119 below the housing shoulder 122. In some instances, theresulting force of the spring 118 will be sufficient to pivot the ballmember 100 before the tubular member 107 moves downwardly far enough toshift the a'butment 119 below the shoulder 122. However, to emphasizethe second function of the spring 118 in supplying the rotational biasto the ball member 100, the abutment 119 is shown slightly below thehousing shoulder 122 in FIG. F. It will also be recognized that as theball member 100 rotates, it will move slightly downwardly into seatingengagement with the lower seat 103. Thus, once the ball member 100- isrotated, the seats 102 and 103 will be tightly seated around theopposite ends of the passage 101 to prevent entrance of fluids in themandrel bore 31 into the enlarged space 93. It will also be noted thatsince the ports 96 and 97 are no longer in registration, solids orfluids in the mandrel bore 31 are similarly blocked from entering theenlarged space 93. Reclosing of the ports 96 and 97 will not, however,permit any pressure differential to be developed across the ball member100'.

Once the tool 20 is in the position shown in FIG. 5F, the mandrel 28will be prevented from traveling upwardly by the co-engagement of theupper mandrel threads 60 in the upper split-nut 51. Release of thethreads 60 from the nut 51 could, of course, be accomplished by rotationof the mandrel 2-8 were it not for the engagement of the upper clutchmember 38 which now prevents further rotation of the mandrel relative tothe housing 29. Thus, once the mandrel 28 reaches its lowermosttelescoped position shown in FIG. 5F, the tool 20 is locked in thisposition with the ball valve means 34 open and the sleeve valve means 33closed. This will provide a substantially continuous and uninterruptedpassage from the tubing string 24 for introduction of various well tools(not shown), completion fluids such as cement or fracturing fluidsrequiring high flow rates, and for other reasons that may be encounteredduring the course of typical remedial or well-completion operations. Thetools 20-23 must be retrieved to the surface in order to return themandrel 28 to its original position. To do this, the upper clutch member38 is quickly released by removing the threaded collar 41 and shiftingthe annular member upwardly to disengage the lugs 39 from the slots 40.

The annular spacer 58 is, of course, employed to pre- 'vent the mandrel28 from being picked upwardly once the ball valve means 34 is opened andthe upper mandrel threads 60 have become engaged with the uppersplit-nut 51 as shown in FIG. 5F. It will be appreciated, therefore,that by omitting this spacer 58, the mandrel 28 could be moved upwardlya suflicient distance to disengage the lugs 39 from their receptiveslots 40. This movement would, however, be insutficient to allow eitherthe ball member 100 to be rotated back into its closed position or forthe ports 96 and 97 to realign as shown in FIG. 5E so long as themandrel 28 was not rotated. Yet, once the lugs 39 were free of theirslots 40, the mandrel 28 could be rotated sufiiciently to disengage theupper split-nut 51 from the mandrel threads 60 and permit the valvemeans 33 and 34 to be alternately opened and closed as many times asdesired between the positions shown in FIGS. 5E and SF. Moreover, withthe spacer 58 omitted, once the mandrel 28 is rotated sufliciently todisengage the upper split-nut 51 :from the upper mandrel threads 60, themandrel could also be returned to any of the positions shown in FIGS.SA-SD as well.

Omission of the spacer 58 is not too desirable, however, where thebypass valve 21 and packer 23 are of the types described above withreference to FIG. 1. For example, following a so-called squeeze job, itis almost essential to rapidly flush-out the excess cement remaining inthe tubing string 24 by applying pressure to the well control fluids inthe well annulus 25 and forcing these fluids up into the lower end ofthe tubing string and on upwardly therein. Access to the tubing string24 is typically gained by either unsetting the packer 23 or, as alastresort, opening the bypass 'valve 21 should the packer not be readilyunseated. It will be realized, of course, that in either event, the ballvalve means 34 of the present invention must be left open to permit ahigh flow rate of these fluids to be maintained. With bypass valves andpackers of the types described, however,the

tubing string 24 usually must be at least partially rotated and thenpicked up with considerable force to either open the bypass valve 21 orunseat the packer 23. These motions could, therefore, serve to reclosethe ball valve means 34 and prevent the desired flushing operation ifeither the packer 23 or bypass valve 21 were not completely free offoreign matter and readily movable. Thus, unless the packer 23 andbypass valve 21 are of a style requiring only a straight upward pull tounseat the packer or open the bypass valve, it is preferred to includethe spacer 58 so that the ball member will unquestionably remainsecurely locked in its open position once the tool 20 is moved into theposition depicted in FIG. 5F.

Turning now to FIG. 6, a partial vie-w is shown of another tool 200 thatis similar to the tool 20 in most respects but includes additionalfeatures of the present invention. As will subsequently become apparent,the tool 200 functions in substantially the same manner as the tool 20except that the mandrel 201 in the tool 200 can be restored to itsinitial extended position relative to its associated housing 202 after aball member therebelow (not shown in FIG. 6 but similar to ball 100 inthe tool 20) is opened and without reclosing the ball member.

To accomplish this, the tool 200 is not equipped with either an upperclutch member or an upper split-nut as are used with the tool 20. This,of course, will allow the mandrel 201 to be rotated relative to thehousing 202 after the ball member (not shown) is opened. In addition,the mandrel 201 is somewhat longer than the mandrel 28 and is comprisedof an upper section 203 that is releasably secured at its lower end bysuitably arranged latch means 204 to the upper end of a lower mandrelsection 205. As for the upper mandrel section 203, it is substantiallylike the mandrel 28 from its up per end down to a point just below thatportion which engages O-ring 83 (FIG. 2C) when the mandrel 28 is in itselevated position. The other mandrel section 205 is substantially likethe remainder of the mandrel 28 from a point just above the mandrelports 96. Thus, in effect, the mandrel 201 can be considered like themandrel 28 with the separated ends and latch means 204 being just abovethe mandrel ports 96. The housing 202 is substantially the same ashousing 29 except that the housing 202 is somewhat longer to accommodatethe latch means 204.

Generally speaking, the mandrel 201 functions in the same manner as themandrel 28 to initially open the ports (corresponding to ports 96 and97) which are not shown in FIG. 6 but are immediately below an O-ring(not shown but just below the shoulder 206) that fluidly seals the lowermandrel section 205 to the housing 202. Similarly, the ball member onbelow these ports is opened in the same manner as the ball member 100.Once the ball member is rotated to its open position, however, the

latch means 204 are disengaged from the upper mandrel A section 203 andnow function to releasably secure the lower mandrel section 205 to thehousing 202 so that the ball member will remain open and to allow theupper mandrel section 203 to be returned] to its initial extendedposition. It will be realized that the lower splitnut as at 52 (notshown in FIG. 6) and lower mandrel threads as at 61 (not shown in FIG.6) are arranged to permit the upper mandrel section 203 to be pulledupwardly without rotation.

Once the upper mandrel section is returned to its initial extendedposition, the lower clutch member (corresponding to member 42) reengagescooperative splines (corresponding to splines 44) to again co-rotativelysecure the mandrel section 203 to the housing 202. In this manner, thetubing string 24 can again transmit torque through the tool 200 tooperate the tools therebelow as, for example, would be necessary toreopen the bypass valve 21 and to unseat the packer 23 arranged as shownin FIG. 1. Once the tools 21-23 are operated as, for example, toreposition the tools and re set the packer, the mandrel section 203 canbe reconnected by the latch means 204 to the lower mandrel section 205to reclose the ball valve. It will be appreciated, of course, that thelower split-nut (corresponding to nut 52) will require the mandrelsection 203 to be progressively lowered and rotated through the samesequence as previously described with reference to FIGS. SA-SF before itcan be relatched to the lower mandrel section 205.

The latch means 204 of the present invention are arranged to accomplishthe selective coupling of the lower mandrel section 205 to either thehousing 202 or the upper mandrel section 203 as desired bytelescopically fitting the lower portion of the upper mandrel sectioninto the upper portion of the lower mandrel section. A shoulder orenlarged-diameter portion 207 on the upper mandrel section 203 abuts theupper end 208 of the lower mandrel section 205 so that when the mandrelsections are coupled together, downward loads can be transmitted to thelower section. The upper portion of the lower mandrel section 205 isprovided with a number of circumferentially spaced lateral openings 209which respectively receive a ball member 210. These ball members 210 areappropriately selected to have a diameter slightly greater than the wallthickness of that portion of the lower mandrel section 205 through whichthe lateral openings 209 are formed.

When the tool 200 is in the position shown in FIGS.

6-8, the immediately adjacent inner wall of the housing 202 is closelyspaced from the outer surface of the lower mandrel section 205. Thus,each of the balls 210 will partially project radially inwardly towardthe outer surface of the lower portion of the upper mandrel section 202and each will be partially received in an adjacent recess 211 formedtherein by a corresponding number of cords or flats 212 of limitedheight cut at circumferentially spaced intervals into the adjacentsurface of the upper mandrel section.

Accordingly, as will be appreciated from FIGS. 6 and 8, the close fit ofthe mandrel sections 203 and 205 with one another and in the housing 202will cause the balls 210 to latch the mandrel sections to one another solong as the flats 212 are opposite the openings 209 and prevent bothrelative rotation and longitudinal movement therebetween withouthampering relative rotation or longitudinal movement of the mandrel 201with respect to the housing. Thus, so long as the mandrel sections 203and 205 are latched together, the mandrel 201 will operate as a unit inthe same manner as mandrel 28. This will, of course, permit the mandrel201 to be operated through the same sequence as the mandrel 28 aspreviously illustrated in FIGS. 5A-5E.

When the mandrel 201 is moved into the position corresponding to thatshown for the mandrel 28 in FIG. 5F, the openings 209 and balls 210 arethen adjacent to a circumferential groove 213 formed around the innersurface of the housing 202. Thus, by rotating the mandrel 201 clockwise,the upper mandrel section 203 will rotate relative to the lower mandrelsection 205 and, as the full diameter of the upper mandrel section comesinto registration with the openings 209, force the balls 210 radiallyoutwardly and into partial reception in the circumferential groove 213.It will be appreciated that the upward force of the spring (as at 118)as well as the frictional restraint of the various O-rings on the lowermandrel section 205 with the housing 202 will be suflicient to permitthe upper mandrel section 203 to be rotated relative thereto at thistime. To limit their relative rotation, the abutting surfaces at 207 and208 are cooperatively keyed to one another as by upwardly extendingfingers 214 loosely received in much wider arcuate slots or recesses 215(FIG. 7) in the shoulder 207. Thus, it will always be possible torecouple the mandrel sections 203 and 205 in the proper orientation Cirall)

to assure the proper cooperation of the flats 212 with the lateralopenings 209.

Once the flats 212 are moved out of registration with the lateralopenings 209, the lower mandrel section 205 will then be secured to thehousing 202 by the balls 210. With the mandrel section 205 secured inthis manner, the ball valve will be held open and the ports (neithershown in FIG. 6) will be closed (as in FIG. 5F) so that the uppermandrel section 203 can be returned to its initial elevated position. Itwill be appreciated that the upper mandrel section 203 is of anappropriate length that its lower portion that is telescoped into thelower section 205 will always be adjacent to the lateral openings 209 soas to hold the balls 210 outwardly and in place in the circumferentialgroove 213.

To recouple the mandrel sections 203 and 205, the upper mandrel sectioncan be returned only by being manipulated through the same sequence asalready described in relation to FIGS. 5A5F. Once, however, the uppermandrel section 203 is again in its telescoped position, it is necessaryonly to rotate it in the reverse direction (counterclockwise) tore-engage the latch means 204 by bringing the flats 212 back intoregistration with the lateral openings 209 and balls 210. With the flats212 again in position, upward movement of the upper mandrel section 203will recouple it through the latch means 204 to the lower mandrelsection 205 so that the ball valve can be reclosed and the mandrel 201moved on to either its intermediate position or its upwardmost extendedposition.

Accordingly, it will be appreciated that the tool 200 can be operatedthrough several sequences during a single trip into the well bore 25rather than being limited to only a single sequence as is the case withthe tool 20. This added flexibility provided by the latch means 204 ofthe present invention will have primary utility where a given well borerequires a number of completion operations at different depths. It willbe recognized, of course, that the tool 200 can be employed with anytype of packer or bypass valve and is not limited in its operation as isthe tool 20. Moreover, the divided mandrel sections 203 and 205 inconjunction with the latch means 204 could be adapted for similar toolswhere the tool had only typical positioning means, such as for example aJ-slot and J-pin arrangement, instead of the positioning means 35described above.

The tool 20 (either with or without the spacer 58) and the tool 200 asdescribed to this point are capable of performing any completion ortesting operation except for measuring so-called downhole or bottompressures. Inasmuch as it is essential to have a full-opening borethrough the tools, as at 31 in the tool 20, for most if not allcompletion operations, it is necessary to provide means for releasablysecuring pressure-measuring devices in or just below the tools 20 or 200in such a manner that these devices can be selectively released andreturned to the surface when a full-opening bore is needed. Heretofore,pressure-measuring devices have been releasably connected tofull-opening tools as, for example, respectively shown on opposite sidesof page 3057 of the aforementioned Composite Catalog.

Although such tools as illustrated in the above-mentioned catalog havebeen sucessfully employed, there have been occasions where thereleasable section (shown on the left of page 3057) is too long tofreely pass through a corkscrewed tubing string. Similarly, thecomplexity of the releasing mechanism of this releasable section hasbeen known to fail for one reason or another so that the entire tubingstring and string of tools must be retrieved in order to release thecenter section.

Accordingly, as another aspect of the present invention, selectivelyreleasable barrier means, such as a pressuremeasuring device 300, areshown in FIG. 9 which are free of the disadvantages mentioned above.Although the pressure-measuring device 300 is shown in position in thetool 20, it will be understood, of course, that this device could justas well be employed with the tool 200. Similarly, although these means300 are described as being for measuring pressures, the same principlescould be employed to releasably secure, either separately or inconjunction with other like or different mechanisms, temperaturesensingdevices, fluid-sampling apparatus, or any number of different completiontools in the tools 20 or 200.

As seen in FIG. 9, the pressure-measuring means 300 are comprised of asupport body 301 connected to the 'upper end of one or more typicalpressure recorders 302 therebelow. The pressure-measuring means 300 aresupported below the ball member 100 by means such as two or moreoutwardly extending shoulders 303 on the body 301 that are adapted torest on an upwardly facing tapered seat 304 formed in the internal boreof a tubular sub 305 appropriately connected to the threads 32 at thelower end of the housing 29. It will be appreciated, of course, that themaximum transverse dimension of the shoulders 303 must be at leastslightly less than the internal diameter of either the ball memberpassage 101 or the mandrel bore 31 (FIGS. 2A-2C) to allow the pressure-measuring means 300 to pass freely therethrough as well as onthrough the tubing string 24. Similarly, no portion of thepressure-measuring means 300 below the shoulders 303 can have atransverse dimension that would prevent its passage past the inwardlyprojecting seat 304.

Accordingly, it will be appreciated that the pressuremeasuring means 300will be trapped between the ball member 100 and the seat 304 so long asthe selectively operable blocking means or ball member is in its closedposition. Inasmuch as the passage 101 is preferably the same diameter asthe mandrel bore 31, once the ball member 100 is in its open position,however, the pressuremeasuring means 300 are no longer trapped below theball member and can be returned to the surface by, for example, applyingpressure to the annulus fluids and reverse circulating them through thebypass valve 21 (or around the unseated packer 23) and back up throughthe bottom of the tool 20. Similarly, when either the spacer 58 (FIG.2A) is not in the tool 20 or the tool 200 is employed, once thepressure-rneasuring means 300 are at the surface, they or other likedevices could be returned through the tubing string 24 to the positionshown in FIG. 9 and the ball member 100 reclosed to again trap thepressure-measuring means.

Although the pressure-measuring means 300 would be suitable with nothingmore than described so far, it is preferred to extend the support body301 upwardly and terminate it with suitable coupling means such as afishing neck 306. The upright body 301 is extended upwardly so that thefishing neck 306- will be near to but spaced just below the bottomsurface of the ball member 100 when that member is in its lowermostposition. This minimum separation limits the distance that thepressure-measuring means 300 can shift due to fluid flow so long as theball member 100 is closed.

Accordingly, it will be appreciated that so long as the valve means 33and 34 are closed, the pressure recorder or recorders 302 will bemeasuring the so-called shutin pressure of the well. Moreover, wheneverthe ports 96 and 97 are opened (FIG. E), the recorder or recorders 302will then measure the pressure of the well as it is flowing. Once theball member 100 is opened, however, the pressure-measuring means 300 arefree and can be returned to the surface through the ball passage 101either by flowing well bore or formation fluids up through the tool 20or by connecting suitable retrieving devices to the fishing neck 306 onthe upright body member 301. As already mentioned, it will be seen thatonce the pressure-measuring means 300 are removed from the tool 20 (ortool 200), a continuous full-opening passage is provided to the wellbore 25 below the packer 23 with the ball member 100 being opened toremove the only other barrier remaining therein.

It will be appreciated that should it be desired to reposition thepressure-measuring means 300 in the tool 20, for example, while it is ina well bore, it would be difiicult to ascertain from the surface whetherthe means were in fact reseated on the seat 304. Accordingly, to providefor this, a pressure-measuring device 400 or other selectively removablebarrier means are arranged as shown in FIG. 10. As seen there, thepressure-measuring means 400 are substantially like those shown in FIG.9 but instead include outwardly biased latching means, such as a pair ofpivoted latch fingers 401 on its central body 402 that are arranged forlatching reception in an annular recess 403 formed in the inner wall ofa tubular housing or sub 404. Compression springs 405 insure that theupper ends of the fingers 401 will enter the recess 403 whenever thepressure-measuring means 400 are in their correct position. Once thefingers 401 spring outwardly and enter the recess 403, the upper ends ofthe fingers will engage the downwardly facing shoulder 406 formed by theupper surface of the recess and prevent the device 400 from beingremoved from the sub 404 until the fingers are retracted. Thus, anupwardly directed force on the device 400 through its retrieving devicewill provide a positive indication that the pressure-measuring means arein fact seated.

To retract the fingers 401, the body 402 is made either tubular or itsupper portion hollowed sufiiciently to provide at least an axial bore407 into which the lower ends of the fingers will project whenever thefingers are extended. Retrieving devices (not fully shown) suspendedfrom a cable and having a suitable coupling or grapple adapted forconnection to the fishing neck 408 on the body 402 are provided with adepending axial extension or probe 409 that will conveniently enter theaxial bore 407 and engage the lower ends of the fingers 401. Then, asthe retrieving device is lowered further into position to couple it tothe fishing neck 408, the probe 409 will move the lower ends of thefingers 401 to retract their upper ends from the recess 403. Once theupper ends of the fingers are free of the recess 403, thepressure-measuring means 400 are freed from the sub 404 and can beretrieved to the surface. It will be realized, of course, that thedepending probe 409 on the retrieving device will maintain the fingers401 in their retracted position as the means 400 are returned to thesurface through the tubing string 24.

The pressure-measuring device 400 can also be returned to its positionas shown in FIG. 10 by either dropping it free through the tubing string24 (FIG. 1) or lowering it with a retrieving device as just describedbut, however, without a depending proble. In this manner, the fingers401 will again re-enter the recess 403 and secure the device 400 againstan upward force applied through the suspension cable that is suflicientto insure first that the pressure-measuring means is again in positionand then disconnect the retrieving device from the fishing neck 408.

The pressure-measuring means 400 must, of course, be returned to thesurface by a cable-suspended retrieving device as just described. Aswill be appreciated, this is not always desirable; and, therefore, asbest seen in FIG. 11, pressure-measuring means 500 are shown there whichcan be released without cable-suspended retrieving apparatus. Theselectively operable barrier means or pressure-measuring device 500 isarranged similar to the pressure-measuring means, 400. As depicted, thepressuremeasuring means 500 are arranged for reception in a housing orsub 501 having a cooperative seat 502 for receiving outwardly projectingshoulders 503 on the tubular central body 504 of the device. Outwardlybiased fingers 505 are pivotally mounted on the body 504 so that theouter ends of the fingers will enter an' internal annular recess 506 inthe sub 501 and engage the downwardly facing shoulder 507 at the upperend of the recess. The upper end of the body 504 is terminated by asuitably arranged fishing neck 508 adapted for reception by a suitablegrapple (not shown).

' The central body 504 receives a slidable member 509 that is releasablysecured therein in an extended position by means, such as a frangiblepin 510, to the central body. With the slidable member 509 secured, itsupper end (not shown) is extended upwardly to a position slightly belowthe lower surface of the ball member (not shown) in the tool, as at 100for example, when the ball member is still closed but the portsthereabove are in registration.

Thus, as will be appreciated from the preceding description of the tools20 and 200, whenever the tool mandrel (not shown) is lowered to reclosethe ports and open the ball member (as depicted in FIG. F), the ballmember will be shifted downwardly against the upper end of the slidablemember 509 with suflicient force to fail the pins 510. Then, as the ballmember is moved on downwardly, the slidable member 509 will movedownwardly in the central member 504 and engage the lower ends of thepivoted fingers 505 to retract their upper ends out of the recess 506.Once the member 509 is freed and moved downwardly, suitable latch means,such as an inwardly biased split-nut 511 in the central body 504 andengageable with external teeth or threads 512 on the slidable member,will secure the slidable member against upward movement.

Accordingly, once the ball member in the tool, as at 200, is open, thefingers 505 will be retracted. This will, of course, permit thepressure-measuring device 500 to be dispatched to the surface by fluidsflowing upwardly through the tool and tubing string 24. The slidablemember 509 and shear pin 510 can be replaced and the device 500 returnedinto position if desired.

It has been demonstrated, therefore, that the tools of the presentinvention provide new and improved means for controlling a cylindricalor spherical valve member. By arranging the actuating springs, as at 118for example, to be selectively engaged by various shoulders, the springsare capable of holding the valve member in one of its positions and thenmoving it to another of its positions as the tool is operated. Moreover,by dividing the mandrel as shown and releasably connecting the twomandrel portions with the latch means depicted in FIGS. 6-8. The lowermandrel portion and ball member can be positively latched in one oftheir positions while the remainder of the mandrel is moved intodiflerent positions.

The various embodiments of the barrier means shown in FIGS. 9-11 alsogive the tools of the present invention more flexibility. By employingsuch barrier means, various operations can be carried out by the toolsand then, once the barrier is removed, still further operations can beconducted.

While particular embodiments of the present invention have been shownand described, it is apparent that changes and modifications may be madewithout departing from this invention in its broader aspects; and,therefore, the aim in the appended claims to cover all such changes andmodifications as fall within the true spirit and scope of thisinvention.

What is claimed is:

1. Well bore apparatus comprising: inner and outer telescoped membersmovable longitudinally in relation to one another between spacedpositions; a second inner member slidably disposed in said outer memberadjacent to said first-mentioned inner member; passage means in saidinner members including an annular valve seat on one of said innermembers; a valve member having a curved portion complementary to saidvalve seat and a flow passage therethrough, said valve member beingdisposed between said valve seat and the other of said inner members andadapted for rotation relative to said valve seat to controlcommunication through said flow passage; first means on one of saidinner members'pivotally supporting said valve member; second meansbetween the other of said inner members and said valve member fortransmitting a turning force to said valve member; and valve-actuatingmeans responsive to movement of said telescoped members for rotatingsaid valve member including first and second opposed shoulders on saidsecond inner member and said outer member respectively and movabletoward one another as said telescoped members are moved from one oftheir said spaced positions to another of their spaced positions,biasing means between said opposed shoulders, and means for isolatingsaid biasing means from at least one of said shoulders until saidtelescoped members are between their said one and other spacedpositions.

2. The apparatus of claim 1 wherein said biasing means include: springmeans having upper and lower ends and adapted for compression betweensaid opposed shoulders to urge said second inner member upwardly as saidfirst inner member is moved downwardly in relation to said outer member.

3. The apparatus of claim 2 wherein said isolating means include: athird shoulder on said second inner member below said first shoulder formaintaining said lower end of said spring means away from said secondshoulder.

4. The apparatus of claim 3 further including: a fourth shoulder on saidouter member above said second shoulder and below said first shoulder solong as said telescoped members are in their said one position; andmeans between said fourth shoulder and said upper end of said springmeans for maintaining said spring means in compression therebetween toprevent rotation of said valve member until said first shoulder isbrought into engage ment with said upper end of said spring means.

5. The apparatus of claim 4 wherein said first inner member has a firstportion separable from a second portion thereof; and further including:means normally latching said first and second inner member portions toone another and releasable upon movement of said first portion in adistinctive manner to free it from said second portion for furtherlongitudinal movement without operating said valve member.

6. The apparatus of claim 5 wherein said latching means further include:means for latching said second inner member portion to said outer memberwhenever said first and second portions of said first inner member arefree from one another to maintain said valve member in one of itspositions.

7. A well tool adapted for connection to a string of pipe andcomprising: inner and outer telescoped tubular members fluidly sealedtogether and longitudinally movable relative to one another between anextended position and progressively-telescoped positions; means forselectively establishing said positions of said tubular members; valvemeans including a valve member pivotally connected along one of its axesto the lower end of said inner member and having a curved portion with atransverse passage therethrough, and an annular valve seat coaxiallymounted on said lower end of said inner member adapted for receivingsaid curved portion of said valve member; and actuating means responsiveto movement of said inner member between two of its said positions forrotating said valve member in relation to said valve seat between aflow-blocking position and a flow-communicating position, said actuatingmeans including an actuating member movably disposed in said outermember adjacent to said valve member, force-transmitting meanseccentrically connecting said actuating member to said valve member forapplying rotational forces thereto, spring means between said actuatingmember and said outer member, first means for engaging One end of saidspring means with one of said two last-mentioned members as said innermember is moved from one of its said two positions toward the other ofits said two positions, and second means for engaging the other end ofsaid spring means with the other of said two last-mentioned membersbefore said inner member reaches its said other position and energizingsaid spring means to develop sufiicient force to rotate said valvemember from one of its said positions to the other of its saidpositions.

8. The well tool of claim 7 further including: second valve meansresponsive to movement of said inner member and adapted for reducing apressure differential across said valve member before said valve memberis rotated into its said flow-communicating position.

9. The well tool of claim 7 further including: third and fourth meansrespectively on said two members and engaging said ends of said springmeans so long as said inner member is in its said one position forenergizing said spring means to maintain said valve member in its saidone position.

10. The well tool of claim 7 wherein said inner member is comprised oftwo separable portions; and further including: means normally latchingsaid separable portions to one another and releasable upon rotation ofthe upper one of said two portions to free it from the lower one of saidtwo portions for further longitudinal movement without operating saidvalve member.

11. The well tool of claim 10 further including: clutch meansco-rotatively securing said upper portion to said outer member wheneversaid upper portion is in at least one position other than said otherposition of said inner member and releasable upon movement of said innermember to its said other position.

12. The well tool of claim 11 wherein said latching means furtherinclude means for latching said lower portion to said outer memberwhenever said upper and lower portions of said inner member are freefrom one another to maintain said valve member in its said otherposition.

13. A well tool adapted for connection to a string of pipe andcomprising: inner and outer telescoped tubular members fluidly sealedtogether and longitudinally movable relative to one another between anextended position and first and second progressively telescopedpositions; means for selectively establishing said positions of saidtelescoped members; first valve means including a port in said innermember and sealing means between said telescoped members for blockingfiuid communication between said port and a lower portion of theinternal bore of said outer member until said telescoped members aremoved from their said extended position to their said first telescopedposition; second valve means including a ball member pivotally connectedalong one of its axes to the lower end of said inner member and having apassage therethrough along another one of its axes transverse to saidpivotal axis, and an annular valve seat coaxially mounted on said lowerend of said inner member receiving said ball member; and actuating meansresponsive to movement of said telescoped members between their saidfirst and second telescoped positions for rotating said ball member inrelation to said valve seat, said actuating means including a tubularactuating member movably disposed in said outer member below said lowerend of said inner member, force-transmitting means eccentricallyconnecting said actuating member to said ball member for applyingrotational forces thereto, spring means between said actuating memberand said outer member and adapted for compression to develop sufficientspring force to rotate said ball member relative to said valve seat froma normal flow-blocking position to a flow-communicating position wheresaid transverse passage is in alignment with said valve seat, a firstshoulder on said actuating member above said compression spring meansand adapted for engagement with the upper end of said compression springmeans, and a second shoulder on said outer member below said firstshoulder and said compression spring means and adapted for engagementwith the lower end of said compression spring means, at least one ofsaid first and second shoulders being spaced from its associated end ofsaid compression spring means until said telescoped members aresubstantially in their said first telescoped position so that saidcompression spring means are not compressed between said first andsecond shoulders until said telescoped members are moved from their saidfirst telescoped position to their said second telescoped position.

14. The well tool of claim 13 further including: means releasablyconnecting said compression spring means between said outer member andsaid actuating member for compressing said compression spring means solong as said telescoped members are in their said extended position anddeveloping sufiicient spring force to maintain said ball member in itssaid flow-blocking position.

15. The well tool of claim 14 wherein said releasable connecting meansinclude: a third shoulder on said outer member between said first andsecond shoulders and engaged with said upper end of said compressionspring means so long as said telescoped members are in their saidextended positions; and a fourth shoulder on said actuating memberengaged with said lower end of said compression spring means and abovesaid second shoulder until said telescoped members are substantially intheir said first telescoped position.

16. The well tool of claim 15 wherein said inner member has an upperportion separable from a longer portion at a point below saidposition-establishing means; and further including: means normallylatching said upper and lower portions to one another and releasableupon rotation of said upper portion relative to said outer memberwhenever said telescoped members are in their said second telescopedposition to free said upper and lower portions from one another andlatch said lower portion to said outer member for maintaining said ballmember in its said flow-communication position.

17. The well tool of claim 15 further including: barrier means adaptedfor passage through said tubular members, said transverse passage, andsaid valve seat; and means below said valve member for supporting saidbarrier means.

18. The well tool of claim 17 further including: means releasablylatching said barrier means in said tool.

19. The well tool of claim 18 further including: means responsive tomovement of said telescoped members to their said second telescopedposition for releasing said releasable latching means and freeing saidbarrier means for passage through said tubular member, said transversepassage, and said valve seat.

20. The well tool of claim 19 wherein said inner mem ber has an upperportion separable from a lower portion at a point below saidposition-establishing means; and further including: means normallylatching said upper and lower portions to one another and releasableupon rotation of said upper portion relative to said outer memberWhenever said telescoped members are in their said second telescopedposition to free said upper and lower portions from one another andlatch said lower portion to said outer member for maintaining said ballmember in its said flow-communicating position.

21. The well tool of claim 19 wherein said movementresponsivelatch-releasing means includes an upright member movably disposedbetween said releasable latching means and said ball member, saidupright member being adapted for engagement by said ball member as saidtelescoped members are moved toward their said second telescopedposition to move said upright member from a first position to a positionfor releasing said releasable latching means.

22. The well tool of claim 21 further including means for securing saidupright member in its latch-releasing position.

23. The well tool of claim 22 further including means for releasablysecuring said upright member in its said first position.

24. Well bore apparatus comprising: inner and outer telescoped membersmovable longitudinally in relation to one another between spacedpositions; a second inner 23 member slidably disposed in said outermember adjacent to said first-mentioned inner member; valve means insaid inner members including an annular valve seat on one of said innermembers and a valve member normally in one position and movably disposedbetween said valve seat and the other of said inner members; andvalveactuating means responsive to movement of said telescoped membersfor moving said valve member to another position including first andsecond opposed shoulders on said second inner member and said outermember respectively and movable toward one another as said telescopedmembers are moved from one of their said spaced positions to another oftheir spaced positions, biasing means between said opposed shoulders,and means for isolating said biasing means from at least one of saidshoulders until said telescoped members are between their said one andother spaced positions.

References Cited UNITED STATES PATENTS Re. 25,471 11/1963 Fredd 166224 X2,894,715 7/1959 Bostock 16672 X 2,998,077 8/1961 Keithahn 166-2263,273,583 9/1966 Dollison 166224 X 3,311,173 3/1967 Henslee et a1.166-226 3,347,318 10/1967 Borrington 166226 3,351,133 11/1967 Clark eta1 166226X 3,356,145 12/1967 Fredd 166224 DAVID H. BROWN, PrimaryExaminer.

